Stable organic-based fluid loss additive containing an organophilic clay-based suspending agent for use in a well

ABSTRACT

A well treatment composition comprises: a water-soluble, organic liquid, wherein the organic liquid: (A) comprises the continuous phase of the well treatment composition; and (B) comprises a polyglycol or a derivative of polyglycol; a fluid loss additive, wherein the fluid loss additive: (A) is insoluble in the organic liquid; and (B) comprises a high molecular weight, water-swellable polymer; and a suspending agent, wherein the suspending agent comprises an organophilic clay, wherein the well treatment composition has an activity of at least 15%. A method of cementing in a subterranean formation comprises: introducing a cement composition into the subterranean formation, the cement composition comprising: (i) cement; (ii) water; and (iii) the well treatment composition; and allowing the cement composition to set after introduction into the subterranean formation.

CROSS-REFERENCE TO RELATED APPLICATIONS

This application is a divisional of prior U.S. application Ser. No.12/795,408, filed Jun. 7, 2010.

TECHNICAL FIELD

A well treatment composition is provided. The well treatment compositioncomprises an organic based fluid loss control additive. A method ofpreparation of the well treatment composition is also provided. A methodof cementing in a subterranean formation using the well treatmentcomposition is also provided. In an embodiment, the subterraneanformation is penetrated by a well.

SUMMARY

According to an embodiment, a well treatment composition comprises: awater-soluble, organic liquid, wherein the organic liquid: (A) comprisesthe continuous phase of the well treatment composition; and (B)comprises a polyglycol or a derivative of polyglycol; a fluid lossadditive, wherein the fluid loss additive: (A) is insoluble in theorganic liquid; and (B) comprises a high molecular weight,water-swellable polymer; and a suspending agent, wherein the suspendingagent comprises an organophilic clay, wherein the well treatmentcomposition has an activity of at least 15%.

According to another embodiment, a method of cementing in a subterraneanformation comprises: introducing a cement composition into thesubterranean formation, the cement composition comprising: (i) cement;(ii) water; and (iii) the well treatment composition; and allowing thecement composition to set.

DETAILED DESCRIPTION

As used herein, the words “comprise,” “have,” “include,” and allgrammatical variations thereof are each intended to have an open,non-limiting meaning that does not exclude additional elements or steps.

It should be understood that, as used herein, “first,” “second,” and“third,” are arbitrarily assigned and are merely intended todifferentiate between two or more monomers, fluids, etc., as the casemay be, and does not indicate any sequence. Furthermore, it is to beunderstood that the mere use of the term “first” does not require thatthere be any “second,” and the mere use of the term “second” does notrequire that there be any “third,” etc.

As used herein, a “fluid” is a substance having a continuous phase thattends to flow and to conform to the outline of its container when thesubstance is tested at a temperature of 71° F. (22° C.) and a pressureof one atmosphere “atm” (0.1 megapascals “MPa”). A fluid can be a liquidor gas. As used herein, a “fluid” can have more than one distinct phase.For example, a “fluid” can be a colloid. As used herein, a “colloid” isa two-phase system in which the dispersed phase remains suspended in thecontinuous phase and does not settle out of the continuous phase. Acolloid can be: a sol, which includes a continuous liquid phase andundissolved nanometer-sized solid particles (<500 nm) as the dispersedphase; an emulsion, which includes a continuous liquid phase and atleast one dispersed phase of immiscible liquid droplets; or a foam,which includes a continuous liquid phase and a gas as the dispersedphase. Another example of a fluid having more than one distinct phase isa suspension. As used herein, a “suspension” is a two-phase system withmicron-sized solid particles dispersed in a liquid continuous phase inwhich the dispersed phase can settle out of the continuous phase overtime or through centrifugation.

As used herein, the term “organic-based” means a suspension or a colloidin which an organic liquid is the continuous phase. As used herein, theterm “organic” means a compound that contains carbon chemically bound tohydrogen. An organic compound can contain other elements, for example,oxygen or nitrogen. As used herein, the term “oil-based” means asuspension or a colloid in which a hydrocarbon liquid is the continuousphase. As used herein, the term “water-based” means a suspension or acolloid in which an aqueous liquid is the continuous phase.

As used herein, a “cement composition” is a mixture of at least cementand water, and possibly other additives. As used herein, the term“cement” means an initially dry substance that, in the presence ofwater, acts as a binder to bind other materials together.

Oil and gas hydrocarbons are naturally occurring in some subterraneanformations. A subterranean formation containing oil or gas is sometimesreferred to as a reservoir. A reservoir may be located under land or offshore. Reservoirs are typically located in the range of a few hundredfeet (shallow reservoirs) to a few tens of thousands of feet (ultra-deepreservoirs). In order to produce oil or gas, a wellbore is drilled intoa reservoir or adjacent to a reservoir.

A well can be an oil, gas, water, or injection well. As used herein, a“well” includes at least one wellbore. A wellbore can include vertical,inclined, and horizontal portions, and it can be straight, curved, orbranched. As used herein, the term “wellbore” includes any cased, anduncased, open-hole portion of the wellbore. A near-wellbore region isthe subterranean material and rock of the subterranean formationsurrounding the wellbore. As used herein, a “well” also includes thenear-wellbore region. The near-wellbore region is generally consideredto be the region within about 100 feet of the wellbore. As used herein,“into a well” means and includes into any portion of the well, includinginto the wellbore or into the near-wellbore region via the wellbore.

A portion of a wellbore may be an open hole or cased hole. In a typicalopen-hole wellbore portion, a tubing string can be placed into thewellbore. The tubing string allows fluids to be introduced into orflowed from a remote portion of the wellbore. In a cased-hole wellboreportion, a casing is placed into the wellbore which can also contain atubing string. A wellbore can contain an annulus. Examples of an annulusinclude, but are not limited to: the space between the wellbore and theoutside of a tubing string in an open-hole wellbore; the space betweenthe wellbore and the outside of the casing in a cased-hole wellbore; andthe space between the tubing string and the inside of the casing in acased-hole wellbore.

During well completion, it is common to introduce a cement compositioninto an annulus in a wellbore. For example, in a cased-hole wellbore, acement composition can be placed into and allowed to set in the annulusbetween the wellbore and the casing in order to stabilize and secure thecasing in the wellbore. By cementing the casing in the wellbore, fluidsare prevented from flowing into the annulus. Consequently, oil or gascan be produced in a controlled manner by directing the flow of oil orgas through the casing and into the wellhead. Cement compositions canalso be used in well-plugging operations or gravel-packing operations.

However, fluids, such as water, included in a cement composition canpenetrate into the surrounding subterranean formation. This is commonlyreferred to as fluid loss. The loss of significant amounts of fluid fromthe cement composition into the formation can adversely affect, interalia, the viscosity, thickening time, setting time, and compressivestrength of the cement composition. Therefore, it is common to include afluid loss additive in a cement composition in order to help minimizethe amount of fluid that is lost from the cement composition into thesubterranean formation.

It is sometimes beneficial to add a well treatment compositioncontaining an additive to a cement composition as a liquid concentrate.For example, a liquid concentrate can be prepared as a colloid. Morespecifically, a liquid concentrate can be prepared as a slurry. Theliquid concentrate can be prepared and can then be added to cement,water, and any other ingredients on the fly at a work site to form acement composition. The cement composition can then be introduced into asubterranean formation.

Water-swellable polymers have been used as a fluid loss additive. Apolymer is a large molecule composed of repeating units typicallyconnected by covalent chemical bonds. A polymer is formed from thepolymerization reaction of monomers. A polymer formed from one type ofmonomer is called a homopolymer. A polymer can be formed from two ormore different types of monomers, and is called a copolymer. In thepolymerization reaction, the monomers are transformed into the repeatingunits of a polymer. The number of repeating units of a polymer can rangefrom approximately 4 to greater than 10,000. The number of repeatingunits of a polymer is referred to as the chain length of the polymer.The conditions of the polymerization reaction can be adjusted to helpcontrol the average number of repeating units (the average chain length)of a polymer. A polymer also has an average molecular weight, which isdirectly related to the average chain length of the polymer. The averagemolecular weight of a polymer has an impact on some of the physicalcharacteristics of a polymer, for example, its solubility in water.

The average molecular weight for a copolymer can be expressed asfollows:

Avg. molecular weight=(M.W.m ₁*RUm ₁)+(M.W.m ₂*RUm ₂) . . .

where M.W.m₁ is the molecular weight of the first monomer; RU m₁ is thenumber of repeating units of the first monomer; M.W.m₂ is the molecularweight of the second monomer; and RU m₂ is the number of repeating unitsof the second monomer. Of course, a terpolymer would include threemonomers, a tetrapolymer would include four monomers, and so on.

Polymer molecules can be cross-linked. As used herein, a “cross-link” or“cross-linking” is a connection between two or more polymer molecules.Cross-linking the polymer molecules can increase the molecular weight ofthe polymer. In general, as the molecular weight of a polymer orcross-linked polymer increases, its solubility decreases. As a result,some high molecular weight polymers can become water swellable whentheir molecular weight increases above a certain limit. As used herein,the term “water swellable” means a polymer or cross-linked polymer thatcan absorb water and can swell. As used herein, a “low molecular weightpolymer” means a polymer or cross-linked polymer with an averagemolecular weight of less than 50,000. As used herein, a “high molecularweight polymer” means a polymer or a cross-linked polymer with anaverage molecular weight of 50,000 or greater.

For a copolymer, the repeating units for each of the monomers can bearranged in various ways along the polymer chain. For example, therepeating units can be random, alternating, periodic, or block.

It can be difficult to make a water-based fluid loss concentrate withsome water-swellable polymers because the polymer can form fish eyes inthe aqueous liquid. A fish eye generally occurs during the process ofblending the water-swellable polymer with the aqueous liquid. Fish eyesare balls of unhydrated polymer surrounded by a gelatinous covering ofhydrated polymer. Fish eyes prevent water from contacting the interiorof the fish eye and the unhydrated polymer contained therein. Fish eyescan be difficult to break apart once formed. A liquid concentratecontaining fish eyes is not a homogenous system. As used herein, theterm “homogenous” means a suspension or a colloid in which the dispersedphase is uniformly dispersed throughout the continuous liquid phase. Itis desirable to have a homogenous liquid concentrate.

In order to avoid the problem of fish-eye formation, an oil-basedsuspension containing a water-swellable polymer can be used. However, anoil-based suspension containing a water-swellable polymer can have poorstability. The water-swellable polymer in an oil-based concentrate canalso stick onto the wall of a container, which can cause difficultyduring pouring. Instability refers to a suspension, in which theuniformly dispersed undissolved solids settle out of the liquidcontinuous phase over time. By contrast, a stable suspension can remainhomogenous over the course of several days to several months.

Another problem with using an oil-based suspension is that thehydrocarbon liquid may not be biodegradable or biocompatible. Becausemany countries have implemented environmental regulations specifying thetypes of fluids and chemicals that may and may not be used in a well,certain oil-based concentrates can be prohibited from being used in awell. Moreover, for an oil-based suspension, the hydrocarbon liquid isnot mixable with the water-based cement composition. As a result,surfactants and other chemicals are required to emulsify the oil in thecement composition, which leads to a more complicated system. Yetanother problem with using an oil-based suspension is that thehydrocarbon liquid is hydrophobic in nature where most fluid lossadditives are hydrophilic in nature. Thus, the hydrophilic fluid lossadditive may not form positive interactions with the hydrophobichydrocarbon liquid. This may lead to particle agglomeration throughparticle-particle interaction and may accelerate settling of the fluidloss additive.

In addition to the problem of fish-eye formation, a water-basedconcentrate that contains a water-swellable polymer can become tooviscous to pour the concentrate out of a blending or storage containerto be included in a cement composition. Viscosity is a measure of theresistance of a fluid to flow, defined as the ratio of shear stress toshear rate. Viscosity can be expressed in units of (force*time)/area.For example, viscosity can be expressed in units of dyne*s/cm² (commonlyreferred to as Poise (P)), or expressed in units of Pascals/second(Pa/s). However, because a material that has a viscosity of 1 P is arelatively viscous material, viscosity is more commonly expressed inunits of centipoise (cP), which is 1/100 P. The viscosity of a materialand pourability are related. The higher the viscosity, the less easilythe material can be poured. Conversely, the lower the viscosity, themore easily the material can be poured. It is desirable for a liquidconcentrate to be pourable.

As used herein, the “viscosity” of a material is measured according toAPI RP 10B-2/ISO 10426-2 as follows. The material to be tested, such asa slurry, is prepared. The material is placed into the test cell of arotational viscometer, such as a FANN® Model 35 viscometer, fitted witha FANN® yield stress adapter (FYSA) and spring number 1. The material istested at ambient temperature and pressure, about 71° F. (22° C.) andabout 1 atm (0.1 MPa). Viscosity can be calculated using the followingequation, expressed in units of

$V = {\frac{k_{1}}{k_{2}}(1000)\frac{\theta}{N}}$

where k₁ is a constant that depends on the FYSA in units of 1/s; k₂ is aconstant that depends on the FYSA in units of Pa; (1000) is theconversion constant from Pa*s to centipoise; e is the dial reading onthe viscometer; and N is the rpm.

Rheology is a unit-less measure of how a material deforms and flows.Rheology includes the material's elasticity, plasticity, and viscosity.As used herein, the “rheology” of a material, such as a slurry or acement composition, is measured as follows. The material to be tested isprepared. The material is placed into the test cell of a rotationalviscometer, such as a FANN® Model 35 viscometer, fitted with a FYSAattachment and a spring number 1. The material is tested at ambienttemperature and pressure, about 71° F. (22° C.) and about 1 atm (0.1MPa). Rheology readings are taken at multiple rpm's, for example, at 3,6, 30, 60, 100, 200, and 300.

Another desirable characteristic of a liquid concentrate is a highamount of activity. As used herein, the term “activity” means the totalpercent of active solids in a liquid. For example, a liquid concentratecan have an activity of 10%, which means that there is 10 gm of activesolid present in 100 gm of liquid concentrate. It is believed that theactivity of a liquid concentrate can be increased by increasing thehomogeneity of the concentrate. It is also believed that the activity ofa liquid concentrate can be increased by increasing active solid loadingin the suspension.

It has been discovered that a well treatment composition can be made asa liquid concentrate comprising: a water-soluble, organic liquid; a highmolecular weight, water-swellable polymer as a fluid loss additive; andan organophilic clay suspending agent. Some of the advantages of thewell treatment composition is that the composition: is more homogenous;is more stable; is less viscous; pours more easily; is soluble in water;and has a higher activity compared to some oil- and water-basedconcentrates.

A liquid concentrate can be added to cement, water, and possibly otheradditives to form a cement composition. During cementing operations, itis desirable for the cement composition to remain pumpable duringintroduction into the subterranean formation and until the cementcomposition is situated in the portion of the subterranean formation tobe cemented. After the cement composition has reached the portion of thesubterranean formation to be cemented, the cement composition canultimately set. A cement composition that thickens too quickly whilebeing pumped can damage pumping equipment or block tubing or pipes, anda cement composition that sets too slowly can cost time and money whilewaiting for the composition to set.

If any test (e.g., thickening time or compressive strength) requires thestep of mixing, then the cement composition is “mixed” according to thefollowing procedure. The water is added to a mixing container and thecontainer is then placed on a mixer base. The motor of the base is thenturned on and maintained at 4,000 revolutions per minute (rpm). Thecement and any other ingredients are added to the container at a uniformrate in not more than 15 seconds (s). After all the cement and any otheringredients have been added to the water in the container, a cover isthen placed on the container, and the cement composition is mixed at12,000 rpm (+/−500 rpm) for 35 s (+/−1 s). It is to be understood thatthe cement composition is mixed at ambient temperature and pressure(about 71° F. (22° C.) and about 1 atm (0.1 MPa)).

It is also to be understood that if any test (e.g., thickening time orcompressive strength) specifies the test be performed at a specifiedtemperature and possibly a specified pressure, then the temperature andpressure of the cement composition is ramped up to the specifiedtemperature and pressure after being mixed at ambient temperature andpressure. For example, the cement composition can be mixed at 71° F.(22° C.) and 1 atm (0.1 MPa) and then placed into the testing apparatusand the temperature of the cement composition can be ramped up to thespecified temperature. As used herein, the rate of ramping up thetemperature is in the range of about 3° F./min to about 5° F./min (about−16° C./min to about −15° C./min). After the cement composition isramped up to the specified temperature and possibly pressure, the cementcomposition is maintained at that temperature and pressure for theduration of the testing.

As used herein, the “thickening time” is how long it takes for a cementcomposition to become unpumpable at a specified temperature andpressure. The pumpability of a cement composition is related to theconsistency of the composition. The consistency of a cement compositionis measured in Bearden units of consistency (Bc), a dimensionless unitwith no direct conversion factor to the more common units of viscosity.As used herein, a cement composition becomes “unpumpable” when theconsistency of the composition reaches 70 Bc. As used herein, theconsistency of a cement composition is measured as follows. The cementcomposition is mixed. The cement composition is then placed in the testcell of a High-Temperature, High-Pressure (HTHP) consistometer, such asa FANN® Model 275 or a Chandler Model 8240. Consistency measurements aretaken continuously until the cement composition exceeds 70 Bc.

A cement composition can develop compressive strength. Cementcomposition compressive strengths can vary from 0 psi to over 10,000 psi(0 to over 69 MPa). Compressive strength is generally measured at aspecified time after the composition has been mixed and at a specifiedtemperature and pressure. Compressive strength can be measured, forexample, at a time of 24 hours. According to ANSI/API RecommendedPractice 10B-2, compressive strength can be measured by either adestructive method or non-destructive method.

The destructive method mechanically tests the compressive strength of acement composition sample taken at a specified time after mixing and bybreaking the samples in a compression-testing device, such as a Super LUniversal testing machine model 602, available from Tinius Olsen,Horsham in Pennsylvania, USA. According to the destructive method, thecompressive strength is calculated as the force required to break thesample divided by the smallest cross-sectional area in contact with theload-bearing plates of the compression-testing device. The compressivestrength is reported in units of pressure, such as pound-force persquare inch (psi) or megapascals (MPa).

The non-destructive method continually measures correlated compressivestrength of a cement composition sample throughout the test period byutilizing a non-destructive sonic device such as an Ultrasonic CementAnalyzer (UCA) available from FANN® Instruments in Houston, Tex., USA.As used herein, the “compressive strength” of a cement composition ismeasured using the non-destructive method at a specified time,temperature, and pressure as follows. The cement composition is mixed.The cement composition is then placed in an Ultrasonic Cement Analyzerand tested at a specified temperature and pressure. The UCA continuallymeasures the transit time of the acoustic signal through the sample. TheUCA device contains preset algorithms that correlate transit time tocompressive strength. The UCA reports the compressive strength of thecement composition in units of pressure, such as psi or MPa.

The compressive strength of a cement composition can be used to indicatewhether the cement composition has initially set or set. As used herein,a cement composition is considered “initially set” when the cementcomposition develops a compressive strength of 50 psi (0.3 MPa) usingthe non-destructive compressive strength method at a temperature of 212°F. (100° C.) and a pressure of 3,000 psi (20 MPa). As used herein, the“initial setting time” is the difference in time between when the cementand any other ingredients are added to the water and when thecomposition is initially set.

As used herein, the term “set,” and all grammatical variations thereof,are intended to mean the process of becoming hard or solid by curing. Asused herein, the “setting time” is the difference in time between whenthe cement and any other ingredients are added to the water and when thecomposition has set at a specified temperature. It can take up to 48hours or longer for a cement composition to set. Some cementcompositions can continue to develop compressive strength over thecourse of several days. The compressive strength of a cement compositioncan reach over 10,000 psi (69 MPa).

Fluid loss from a cement composition can occur. As used herein, the“fluid loss” of a cement composition is tested according to the APIstatic fluid loss procedure at a specified temperature and pressuredifferential as follows. The cement composition is mixed. The cementcomposition is placed into an atmospheric consistometer, such as a FANN®Model 165 AT consistometer, heated to the specified temperature, andthen maintained at the specified temperature for 20 minutes. A test cellof a fluid loss test assembly, such as a FANN® fluid loss test assembly,is pre-heated to the specified temperature. The cement composition isthen placed into the test cell of the fluid loss test assembly. Thecement composition is then tested for fluid loss at the specifiedpressure differential. Fluid loss is measured in milliliters (mL) per 30minutes (min). The total mL of fluid loss is then multiplied by 2 toobtain the API fluid loss for the cement composition and expressed inunits of mL/30 min.

According to an embodiment, a well treatment composition comprises: awater-soluble, organic liquid, wherein the organic liquid: (A) comprisesthe continuous phase of the well treatment composition; and (B)comprises a polyglycol or a derivative of polyglycol; a fluid lossadditive, wherein the fluid loss additive: (A) is insoluble in theorganic liquid; and (B) comprises a high molecular weight,water-swellable polymer; and a suspending agent, wherein the suspendingagent comprises an organophilic clay, wherein the well treatmentcomposition has an activity of at least 15%.

According to another embodiment, a method of cementing in a subterraneanformation comprises: introducing a cement composition into thesubterranean formation, the cement composition comprising: (i) cement;(ii) water; and (iii) the well treatment composition; and allowing thecement composition to set.

The discussion of preferred embodiments regarding the well treatmentcomposition, or any ingredient in the well treatment composition, isintended to apply to the composition embodiments and the methodembodiments. Any reference to the unit “gallons” means U.S. gallons. Asused herein, the term “soluble” means that at least 1 part of thesubstance dissolves in 20 parts of the liquid at a temperature of 75° F.(24° C.) and a pressure of 1 atm (0.1 MPa). As used herein, the term“insoluble” means that less than 1 part of the substance dissolves in 20parts of the liquid at a temperature of 75° F. (24° C.) and a pressureof 1 atm (0.1 MPa).

The well treatment composition includes a water-soluble, organic liquid,wherein the organic liquid comprises the continuous phase of the welltreatment composition, and wherein the organic liquid comprises apolyglycol or a derivative of polyglycol. The well treatment compositioncan be a liquid concentrate. The well treatment composition can be acolloid, wherein the organic liquid comprises the continuous phase ofthe colloid. For a colloid, the organic liquid can contain dissolvedsolids. In one embodiment, the well treatment composition is asuspension.

It is preferred that the organic liquid is biocompatible. As usedherein, “biocompatible” means the quality of not having toxic orinjurious effects on biological systems. For example, if the welltreatment composition is used in off-shore drilling, then a release ofthe organic liquid into the water would not be harmful to aquatic life.

The organic liquid comprises a polyglycol or a derivative of polyglycol.In an embodiment, the organic liquid is a linear homopolymer. Theorganic liquid can be selected from the group consisting of polyetherglycol, polyester glycol, polyether ester glycol, and any combinationthereof. In one embodiment, the organic liquid has an average molecularweight of at least 150. In another embodiment, the organic liquid has anaverage molecular weight of at least 200. In another embodiment, theorganic liquid has an average molecular weight in the range of about 150to about 1,000.

The well treatment composition includes a fluid loss additive, whereinthe fluid loss additive is insoluble in the organic liquid, and whereinthe fluid loss additive comprises a high molecular weight,water-swellable polymer. It is preferable that the fluid loss additiveis non-retarding. As used herein, the term “non-retarding” means thefluid loss additive does not substantially delay the setting time of acement composition that contains the fluid loss additive compared to asubstantially identical cement composition except without the fluid lossadditive.

The polymer for the fluid loss additive can comprise: cellulose; guar;xanthan; starch; a monomer or monomers selected from the groupconsisting of acrylamido-methyl-propane sulfonate (AMPS),N-vinyl-N-methylaceamide, N-vinylformamide, N-vinylpyrrolidone,acrylonitrile, acrylamide, acrylomorpholine, vinyl alcohol, maleicanhydride, acrylic acid, methacrylic acid; derivatives of any of theforegoing; and any combination thereof. Preferably, the polymer is acopolymer. For a copolymer, preferably one of the monomers is AMPS. Ifthe polymer is a copolymer, then the repeating units of the polymer canbe random. Suitable commercially-available examples of a fluid lossadditive include, but are not limited to, HALAD®-344, HALAD®-300, andHALAD®-400, marketed by Halliburton Energy Services, Inc. in Duncan,Okla., USA.

The polymer for the fluid loss additive is a high molecular weightpolymer. The polymer can have an average molecular weight of at least50,000. In one embodiment, the polymer has an average molecular weightin the range of about 50,000 to about 2,000,000. In another embodiment,the polymer has an average molecular weight in the range of about500,000 to about 1,250,000.

The polymer for the fluid loss additive is generally water swellable.

In one embodiment, the fluid loss additive is in a concentration of atleast 15% by weight of the well treatment composition. In anotherembodiment, the fluid loss additive is in a concentration in the rangeof about 15% to about 80% by weight of the well treatment composition.In another embodiment, the fluid loss additive is in a concentration inthe range of about 20% to about 50% by weight of the well treatmentcomposition.

The well treatment composition includes a suspending agent, wherein thesuspending agent comprises an organophilic clay. As used herein, theterm “suspending agent” means a material that is capable of suspendingsolid particles with a mesh size below 60 in an organic liquid for aperiod of at least 5 hours at a temperature of 71° F. (22° C.). Anysuspending agent that is an organophilic clay and capable of suspendingsolid particles in the continuous phase of the well treatmentcomposition is suitable for use in the liquid concentrate. Preferably,the suspending agent is insoluble in the organic liquid. As used herein,an “organophilic clay” is a clay possessing a cationic exchange capacitythat has been coated with a fatty-acid quaternary amine that associateswith an organic liquid. Examples of suitable clays are organophilicbentonite, hectorite, attapulgite, sepiolite, and combinations thereof.Preferably, the clay is organophilic attapulgite. A commerciallyavailable example of an organophilic clay is SUSPENTONE®, marketed byHalliburton in Duncan, Okla., USA.

In one embodiment, the suspending agent is in a concentration of atleast 0.05% by weight of the well treatment composition. In anotherembodiment, the suspending agent is in a concentration in the range ofabout 0.05% to about 5% by weight of the well treatment composition. Inanother embodiment, the suspending agent is in a concentration in therange of about 0.75% to about 3% by weight of the well treatmentcomposition.

It is preferred that the well treatment composition is homogenous.Preferably, the suspending agent is in at least a sufficientconcentration such that the liquid concentrate is homogenous.

In one embodiment, the well treatment composition has a viscosity suchthat the well treatment composition is capable of being poured. Forexample, if the well treatment composition is to be included in a cementcomposition, then the well treatment composition can be poured from acontainer into a different mixing apparatus for forming the cementcomposition. In one embodiment, the well treatment composition has aviscosity of less than 50,000 cP (50,000 millipascals/second “mPa/s”).Preferably, the suspending agent is in a concentration equal to or lessthan a sufficient concentration such that the well treatment compositionhas a viscosity of less than 50,000 cP. Preferably, the fluid lossadditive is in a concentration equal to or less than a sufficientconcentration such that the well treatment composition has a viscosityof less than 50,000 cP. In another embodiment, the well treatmentcomposition has a viscosity of less than 25,000 cP (25,000 mPa/s).

In one embodiment, the well treatment composition has an activity of atleast 15%. Preferably, the suspending agent is in at least a sufficientconcentration such that the well treatment composition has an activityof at least 15%. In another embodiment, the well treatment compositionhas an activity of at least 40%. In another embodiment, the welltreatment composition has an activity of at least 60%.

According to an embodiment, a method for cementing in a subterraneanformation comprises: introducing a cement composition into thesubterranean formation, the cement composition comprising: (i) cement;(ii) water; and (iii) the well treatment composition; and allowing thecement composition to set.

The method can further include the step of making the well treatmentcomposition prior to the step of introducing. According to thisembodiment, the step of making comprises blending the well treatmentcomposition. Preferably, the well treatment composition is blended suchthat the well treatment composition is homogenous. Preferably, the welltreatment composition is blended for a sufficient length of time toprovide a homogenous well treatment composition. The well treatmentcomposition can be blended via stirring the well treatment compositionwith a mechanical stirrer or mixing the well treatment composition witha constant-speed blender. Preferably, the well treatment composition isblended using a constant-speed blender and is blended at 4,000 rpm.

The method can further include the step of pre-blending the organicliquid and the suspending agent. According to this embodiment, the stepof pre-blending is performed, then the fluid loss additive is added tothe pre-blended mixture, then the step of blending is performed. Themethod can further include the step of heating the organic liquid to atemperature of at least 176° F. (80° C.) before the step of blending orbefore the step of pre-blending. If a pre-blending step is included inthe method, then the pre-blending step can further include the step ofallowing to cool or cooling the organic liquid/suspending agent mixtureprior to the step of adding the fluid loss additive. By way of example,the well treatment composition can be blended according to the followingprocedure. First, the organic liquid is heated to a temperature of atleast 176° F. (80° C.). Second, the organic liquid is added to apre-heated blending container, then the suspending agent is added to theblending container, and then the organic liquid and the suspending agentare pre-blended. Preferably, the organic liquid and suspending agent arepre-blended for at least 5 minutes at 4,000 rpm. Third, the organicliquid/suspending agent mixture is cooled or allowed to cool to atemperature of about 122° F. (50° C.). Fourth, the fluid loss additiveis added to the blending container. Fifth, the step of blending isperformed for at least 5 min at 4,000 rpm.

The method for making the well treatment composition can further includethe step of storing the well treatment composition after the step ofblending and prior to the step of introducing. In one embodiment, thewell treatment composition is capable of being stored and duringstorage, the well treatment composition maintains the followingcharacteristics: it is stable, it is homogenous, and it is capable ofbeing poured. Preferably, the well treatment composition is capable ofbeing stored for a time of 6 months or more, while maintaining thecharacteristics listed above.

The cement composition includes cement. The cement can be Class Acement, Class C cement, Class G cement, Class H cement, and anycombination thereof. Preferably, the cement is Class G cement or Class Hcement.

The cement composition includes water. The water can be selected fromthe group consisting of freshwater, brackish water, saltwater, and anycombination thereof. The cement composition can further include awater-soluble salt. As used herein, “water-soluble salt” means greaterthan 1 part of the salt dissolves in 5 parts of water at a temperatureof 80° F. (27° C.). Preferably, the salt is selected from sodiumchloride, calcium chloride, calcium bromide, potassium chloride,potassium bromide, magnesium chloride, and any combination thereof. Thecement composition can contain the water-soluble salt in a concentrationin the range of about 5% to about 35% by weight of the water (bww).

The cement composition includes the fluid loss additive for the welltreatment composition. In one embodiment, the fluid loss additive is ina concentration of at least 0.05% by weight of the cement (bwc). Inanother embodiment, the fluid loss additive is in a concentration of atleast 1% bwc. In another embodiment, the fluid loss additive is in aconcentration in the range of about 0.05% to about 5% bwc.

The cement composition includes the suspending agent for the welltreatment composition. In one embodiment, the suspending agent is in aconcentration of at least 0.01% bwc. In another embodiment, thesuspending agent is in a concentration in the range of about 0.01% toabout 2% bwc. In another embodiment, the suspending agent is in aconcentration in the range of about 0.02% to about 1% bwc.

In an embodiment, the cement composition has a thickening time of atleast 3 hours at a temperature of 125° F. (51° C.) and a pressure of5,160 psi (36 MPa). In another embodiment, the cement composition has athickening time in the range of about 4 to about 15 hours at atemperature of 125° F. (51° C.) and a pressure of 5,160 psi (36 MPa).Some of the variables that can affect the thickening time of the cementcomposition include the concentration of any set retarder included inthe cement composition, the concentration of any salt present in thecement composition, and the bottomhole temperature of the subterraneanformation. As used herein, the term “bottomhole” refers to the portionof the subterranean formation to be cemented. In another embodiment, thecement composition has a thickening time of at least 3 hours at thebottomhole temperature and pressure of the subterranean formation.

In one embodiment, the cement composition has an initial setting time ofless than 24 hours at a temperature of 125° F. (51° C.) and a pressureof 3,000 psi (21 MPa). In another embodiment, the cement composition hasan initial setting time of less than 24 hours at the bottomholetemperature and pressure of the subterranean formation.

Preferably, the cement composition has a setting time of less than 48hours at a temperature of 125° F. (51° C.). More preferably, the cementcomposition has a setting time of less than 24 hours at a temperature of125° F. (51° C.). Most preferably, the cement composition has a settingtime in the range of about 3 to about 24 hours at a temperature of 125°F. (51° C.). In another embodiment, the cement composition has a settingtime of less than 48 hours at the bottomhole temperature and pressure ofthe subterranean formation.

Preferably, the cement composition has a compressive strength of atleast 500 psi (3.5 MPa) when tested at 24 hours, a temperature of 125°F. (51° C.), and a pressure of 3,000 psi (21 MPa). More preferably, thecement composition has a compressive strength in the range of about 500to about 10,000 psi (about 3.5 to about 69 MPa) when tested at 24 hours,a temperature of 125° F. (51° C.), and a pressure of 3,000 psi (21 MPa).

In one embodiment, the cement composition has an API fluid loss of lessthan 155 mL/30 min at a temperature of 125° F. (51° C.) and a pressuredifferential of 1,000 psi (7 MPa). Preferably, the fluid loss additiveis in at least a sufficient concentration such that the cementcomposition has the desired API fluid loss. In another embodiment, thecement composition has an API fluid loss of less than 100 mL/30 min at atemperature of 125° F. (51° C.) and a pressure differential of 1,000 psi(7 MPa). In another embodiment, the cement composition has an API fluidloss of less than 60 mL/30 min at a temperature of 125° F. (51° C.) anda pressure differential of 1,000 psi (7 MPa).

The cement composition can further include an additional additive.Examples of an additional additive include, but are not limited to, afiller, a set retarder, a friction reducer, a strength-retrogressionadditive, a high-density additive, a set accelerator, a mechanicalproperty enhancing additive, a lost-circulation material, afiltration-control additive, a defoaming agent, a thixotropic additive,a nano-particle, and combinations thereof.

The cement composition can include a filler. Suitable examples offillers include, but are not limited to, fly ash, sand, clays, andvitrified shale. Preferably, the filler is in a concentration in therange of about 5% to about 50% by weight of the cement (bwc).

The cement composition can include a set retarder. Suitable examples ofcommercially-available set retarders include, but are not limited to,HR®-4, HR®-5, HR®-6, HR®-12, HR®-20, HR®-25, SCR-100™ and SCR-500™,marketed by Halliburton Energy Services, Inc. in Duncan, Okla., USA.Preferably, the set retarder is in a concentration in the range of about0.05% to about 10% bwc.

The cement composition can include a friction reducer. Suitable examplesof commercially-available friction reducers include, but are not limitedto, CFR-2™, CFR-3™, CFR-5LE™, CFR-6™, and CFR-8™, marketed byHalliburton Energy Services, Inc. in Duncan, Okla., USA. Preferably, thefriction reducer is in a concentration in the range of about 0.1% toabout 10% bwc.

The cement composition can include a strength-retrogression additive.Suitable examples of commercially-available strength-retrogressionadditives include, but are not limited to, SSA-1™ and SSA-2™, marketedby Halliburton Energy Services, Inc. in Duncan, Okla., USA. Preferably,the strength-retrogression additive is in a concentration in the rangeof about 5% to about 50% bwc.

Commercially-available examples of other additives include, but are notlimited to: HIGH DENSE® No. 3, HIGH DENSE® No. 4, BARITE™, andMICROMAX™, heavy-weight additives; SILICALITE™, extender andcompressive-strength enhancer; WELLLIFE® 665, WELLLIFE® 809, andWELLLIFE® 810 mechanical property enhancers (marketed by HalliburtonEnergy Services, Inc. in Duncan, Okla., USA); and HGS6000™, HGS4000™,and HGS10000™ low-density additives (available from 3M in St. Paul,Minn., USA).

In one embodiment, the cement composition has a density of at least 10pounds per gallon (ppg) (1.2 kilograms per liter (kg/1)). In anotherembodiment, the cement composition has a density of at least 15 ppg (1.8kg/1). In another embodiment, the cement composition has a density inthe range of about 15 to about 20 ppg (about 1.8 to about 2.4 kg/1).

The method includes the step of introducing the cement composition intoa subterranean formation. The step of introducing is for the purpose ofat least one of the following: well completion; foam cementing; primaryor secondary cementing operations; well-plugging; and gravel packing.The cement composition can be in a pumpable state before and duringintroduction into the subterranean formation. In one embodiment, thecement composition is used in a subterranean formation having abottomhole temperature of at least 150° F. (66° C.). In anotherembodiment, the bottomhole temperature is in the range of about 150° F.to about 500° F. (66° C. to 260° C.). In another embodiment, thebottomhole temperature is in the range of about 180° F. to about 400° F.(82° C. to 204° C.). In another embodiment, the bottomhole temperatureis in the range of about 180° F. to about 350° F. (82° C. to 177° C.).

In one embodiment, the subterranean formation is penetrated by a well.The well can be an oil, gas, water, or injection well. According to thisembodiment, the step of introducing includes introducing the cementcomposition into the well. According to another embodiment, thesubterranean formation is penetrated by a well and the well includes anannulus. According to this other embodiment, the step of introducingincludes introducing the cement composition into a portion of theannulus.

The method also includes the step of allowing the cement composition toset. The step of allowing can be after the step of introducing thecement composition into the subterranean formation. The method caninclude the additional steps of perforating, fracturing, or performingan acidizing treatment, after the step of allowing.

EXAMPLES

To facilitate a better understanding of the preferred embodiments, thefollowing examples of certain aspects of the preferred embodiments aregiven. The following examples are not the only examples that could begiven according to the preferred embodiments and are not intended tolimit the scope of the invention.

For the data contained in the following tables, the concentration of anyingredient in a suspension or a cement composition can be expressed as:by weight of the suspension (abbreviated as “bws”); or by weight of thecement (abbreviated as “bwc”). HALAD®-344 fluid loss additive is awater-swellable AMPS based random co-polymer, having an averagemolecular weight of >50,000. SUSPENTONE™ suspending agent is a blend ofclays with the majority of the blend being organophilic attapulgite.HALAD®-344 EXP is an oil-based suspension containing mineral oil as thecontinuous phase of the suspension and HALAD®-344 fluid loss additive ata concentration of 38% by weight of the suspension.

Any of the suspensions containing SUSPENTONE® suspending agent wereprepared as follows. The organic liquid was heated to a temperature of176° F. (80° C.). The organic liquid was then added to a pre-heated,hard glass container. The suspending agent was then added to thecontainer and the organic liquid and suspending agent was blended usinga constant speed blender at 2,000-3,000 rpm for 5 min. The mixture wascooled to 122° F. (50° C.) and then transferred to a pre-heated constantspeed blender (FANN® Instruments, Model 676). The fluid loss additivewas then added to the blending container containing the organicliquid/suspending agent mixture. The mixture was then blended in theconstant speed blender at 4,000 to 10,000 rpm for 4 to 10 minutes. Thesuspension was then allowed to cool to ambient temperature (71° F.). Allcement compositions were mixed and tested according to the specifiedprocedure for the specific test as described in The Detailed Descriptionsection above.

Table 1 contains viscosity data for several concentrates. One of theconcentrates was HALAD®-344 EXP. The other two concentrates wereorganic-based suspensions prepared with an organic liquid ofpolyethylene glycol (200) (PEG 200) as the continuous phase, HALAD®-344fluid loss additive at a concentration of 30% bws, and SUSPENTONE®suspending agent at a concentration of 0.75% and 1% bws, respectively.The concentrates were tested for viscosity using a Brookfield viscometerusing an S64 spindle at an rpm of 12 and a temperature of 71° F. (22°C.). As can be seen in Table 1, both of the organic-based suspensionsexhibited a lower viscosity compared to HALAD®-344 EXP. Also, as can beseen, the organic-based suspension with SUSPENTONE™ suspending agent ata concentration of 0.75% bws had a lower viscosity compared to theorganic-based suspension with SUSPENTONE™ suspending agent at aconcentration of 1% bws.

TABLE 1 Type of Liquid Concentrate Viscosity (cP) HALAD ®-344 EXP 11,248Organic-based slurry with 0.75% SUSPENTONE ™ 6,300 Organic-based slurrywith 1% SUSPENTONE ™ 9,248

Tables 2a and 2b contain rheology and viscosity data for two differentconcentrates. For Tables 2a and 2b, k₁=0.289 in 1/s; and k₂=0.703 in Pa.Table 2a contains data for HALAD®-344 EXP. Table 2b contains data for anorganic-based suspension containing PEG 200 as the continuous phase,HALADC)-344 fluid loss additive at a concentration of 30% bws, andSUSPENTONE™ suspending agent at a concentration of 1% bws.

As can be seen in Tables 2a and 2b, the organic-based suspension (Table2b) exhibited better rheologies and lower viscosities compared toHALAD®-344 EXP (Table 2a).

TABLE 2a Shear Rate Dial Shear Stress Viscosity Viscosity rpm (1/sec)Reading (Pa) (Pa*s) (cP) 3 0.867 28 19.684 22.7036 22703.58 6 1.734 3423.902 13.7843 13784.31 30 8.67 70 49.210 5.6759 5675.89 60 17.34 10473.112 4.2164 4216.38 100 28.9 139 97.717 3.3812 3381.21 200 57.8 218153.254 2.6515 2651.45 300 86.7 298 209.494 2.4163 2416.31 600 173.4+300 — — —

TABLE 2b Shear Rate Dial Shear Stress Viscosity Viscosity rpm (1/sec)Reading (Pa) (Pa*s) (cP) 3 0.867 22 15.466 17.8385 17838.52 6 1.734 2517.575 10.1355 10135.52 30 8.67 49 34.447 3.9731 3973.13 60 17.34 7351.319 2.9596 2959.57 100 28.9 102 71.706 2.4812 2481.18 200 57.8 163114.589 1.9825 1982.51 300 86.7 215 151.145 1.7433 1743.31 600 173.4+300 — — —

Table 3 contains rheology and fluid loss data for two different cementcompositions having a density of 16.4 ppg (2 kilograms per liter(kg/1)). In one cement composition, powdered HALAD®-344 fluid lossadditive was added to Class H cement and deionized water (DI) to formthe cement composition. In another cement composition, an organic-basedsuspension was prepared with PEG 200 as the continuous phase of thesuspension, HALAD®-344 fluid loss additive at a concentration of 30%bws, and SUSPENTONE™ suspending agent at a concentration of 1% bws, andthe suspension was then added to Class H cement and DI water to form thecement composition. The concentration of HALAD®-344 fluid loss additive,either as a powder or from HALAD®-344 EXP and the organic-basedsuspensions, is expressed as a percentage by weight of the cement (%bwc) considering the active solid content. For example, if powderedHALAD®-344 fluid loss additive was added at a concentration of 0.6% bwc,then for an organic-based suspension containing HALAD®-344 fluid lossadditive at a concentration of 30% bws, a calculated volume of thesuspension was added to the cement and water to form a cementcomposition such that there was 0.6% bwc of HALAD®-344 fluid lossadditive in the cement composition. The cement compositions were testedfor fluid loss at a temperature of 125° F. (51° C.) and a pressuredifferential of 1,000 psi (7 MPa).

As can be seen in Table 3, the cement composition containing theorganic-based suspension exhibited similar rheologies and fluid losscompared to the cement composition containing HALAD®-344 fluid lossadditive as a powder.

TABLE 3 Concen. of Source of HALAD ®- Temp. Rotational Viscometer FluidLoss HALAD ®-344 344 (% bwc) (° F.) 300 200 100 6 3 (mL/30 min) Powder0.6 125 184 142 86 8 7 38 Organic-based 0.6 125 170 127 82 13 8 44suspension

Table 4 contains thickening time, initial setting time, time to reach500 psi, and compressive strength data for several cement compositionshaving a density of 16.4 ppg (2 kg/1). In one cement composition,powdered HALAD®-344 fluid loss additive was added to Class H cement andDI water to form the cement composition. In another cement composition,HALAD®-344 EXP was added to Class H cement and DI water to form thecement composition. In another cement composition, an organic-basedsuspension was prepared using PEG 200 as the continuous phase,HALAD®-344 fluid loss additive at a concentration of 30% bws, andSUSPENTONE® suspending agent at a concentration of 1% bws, and thesuspension was then added to Class H cement and DI water to form thecement composition. Each of the cement compositions contained HALAD®-344fluid loss additive at a concentration of 0.6% bwc and HR®5 set retarderat a concentration of 0.2% bwc. The thickening time test was conductedat a temperature of 125° F. (51° C.) and a pressure of 5,160 psi (36MPa). The tests for initial setting time, time to reach 500 psi, andcompressive strength were conducted at a temperature of 125° F. (51° C.)and a pressure of 3,000 psi (21 MPa).

As can be seen in Table 4, the cement composition containing theorganic-based suspension had a longer thickening time, initial settingtime, and time to reach 500 psi compared to both, the cement compositioncontaining powdered HALAD®-344 fluid loss additive and the cementcomposition containing HALAD®-344 EXP. The cement composition containingthe organic-based suspension had a lower 24 hrs compressive strengthcompared to both, the cement composition containing HALAD®-344 fluidloss additive as a powder and the cement composition containingHALAD®-344 EXP. These results suggest the organic-based suspension hadlittle retardation effect on the cement composition.

TABLE 4 Non-Destructive Compressive Strength Initial Time to ThickeningSetting Reach Compressive Source of Time Time 500 psi Strength atHALAD ®-344 (hr:min) (hr:min) (hr:min) 24 hrs (psi) Powder 10:27 17:3519:38 1595.5 HALAD ®-  8:15 17:36 19:36 1613.4 344 EXP Organic-based12:07 18:53 21:15 1180.2 suspension

The experiments for Table 5 were conducted to evaluate the salttolerance of an organic-based suspension. Table 5 contains rheology andfluid loss data for two different cement compositions having a densityof 16.5 ppg (2 kg/1). The cement compositions were tested for fluid lossat a temperature of 135° F. (57° C.) and a pressure differential of1,000 psi (7 MPa). Each of the cement compositions contained at leastClass H cement, DI water, 10% bwc of sodium chloride, 0.6% bwcHALAD®-344 fluid loss additive, and 0.1% bwc of HR®-5 set retarder. Oneof the cement compositions included powdered HALAD®-344 and did notinclude a suspending agent. The other cement composition included anorganic-based suspension that contained PEG 200 as the continuous phase,30% bws HALAD®-344 fluid loss additive, and 1% bws SUSPENTONE®suspending agent.

As can be seen in Table 5, the cement composition containing theorganic-based suspension exhibited similar rheologies and a lower fluidloss compared to the cement composition containing powdered HALAD®-344fluid loss additive.

TABLE 5 Source of Temp. Rotational Viscometer Fluid Loss HALAD ®-344 (°F.) 300 200 100 6 3 (mL/30 min) Powder 135 169 121 74 16 11 200.8Organic-based 135 119 90 58 19 15 154.9 suspension

Table 6 contains thickening time, rheology, and fluid loss data for twodifferent cement compositions, having a density of 15.8 ppg (1.9 kg/1).The thickening time test was conducted at a temperature of 125° F. (51°C.) and a pressure of 5,160 psi (36 MPa). The cement compositions weretested for fluid loss at a temperature of 125° F. (51° C.) and apressure differential of 1,000 psi (7 MPa). In one cement composition,powdered HALAD®-344 fluid loss additive was added to Class G cement andDI water to form the cement composition. In another cement composition,an organic-based suspension was prepared using PEG 200 as the continuousphase, 30% bws HALAD®-344 fluid loss additive, and 1% bws SUSPENTONE®suspending agent, and the suspension was then added to Class G cementand DI water to form the cement composition. Each of the cementcompositions contained HALAD®-344 fluid loss additive at a concentrationof 0.6% bwc.

As can be seen in Table 6, the cement composition containing theorganic-based suspension had a lower thickening time, better rheologies,and a lower fluid loss compared to the cement composition containingpowdered HALAD®-344 fluid loss additive. As can also be seen, theorganic-based suspension is compatible with Class G cement.

TABLE 6 Thick. Source of Time Temp. Rotational Viscometer Fluid LossHALAD ®-344 (hr:min) (° F.) 300 200 100 6 3 (mL/30 min) Powder 2:00 125220 187 110 35 25 94 Organic-based 1:52 125 192 146 94 14 9 54suspension

Therefore, the present invention is well adapted to attain the ends andadvantages mentioned as well as those that are inherent therein. Theparticular embodiments disclosed above are illustrative only, as thepresent invention may be modified and practiced in different butequivalent manners apparent to those skilled in the art having thebenefit of the teachings herein. Furthermore, no limitations areintended to the details of construction or design herein shown, otherthan as described in the claims below. It is, therefore, evident thatthe particular illustrative embodiments disclosed above may be alteredor modified and all such variations are considered within the scope andspirit of the present invention. While compositions and methods aredescribed in terms of “comprising,” “containing,” or “including” variouscomponents or steps, the compositions and methods also can “consistessentially of” or “consist of” the various components and steps.Whenever a numerical range with a lower limit and an upper limit isdisclosed, any number and any included range falling within the range isspecifically disclosed. In particular, every range of values (of theform, “from about a to about b,” or, equivalently, “from approximately ato b,” or, equivalently, “from approximately a to b”) disclosed hereinis to be understood to set forth every number and range encompassedwithin the broader range of values. Also, the terms in the claims havetheir plain, ordinary meaning unless otherwise explicitly and clearlydefined by the patentee. Moreover, the indefinite articles “a” or “an”,as used in the claims, are defined herein to mean one or more than oneof the element that it introduces. If there is any conflict in theusages of a word or term in this specification and one or more patent(s)or other documents that may be incorporated herein by reference, thedefinitions that are consistent with this specification should beadopted.

1. A well treatment composition comprising: a water-soluble, organicliquid, wherein the organic liquid: (A) comprises the continuous phaseof the well treatment composition; and (B) comprises a polyglycol or aderivative of polyglycol; a fluid loss additive, wherein the fluid lossadditive: (A) is insoluble in the organic liquid; and (B) comprises ahigh molecular weight, water-swellable polymer; and a suspending agent,wherein the suspending agent comprises an organophilic clay, wherein thewell treatment composition has an activity of at least 15%.
 2. Thecomposition according to claim 1, wherein the well treatment compositionis homogenous.
 3. The composition according to claim 1, wherein the welltreatment composition is a suspension.
 4. The composition according toclaim 1, wherein the organic liquid is a linear polymer.
 5. Thecomposition according to claim 4, wherein the organic liquid is selectedfrom the group consisting of, polyether glycol, polyester glycol,polyether ester glycol, and any combination thereof.
 6. The compositionaccording to claim 5, wherein the organic liquid has an averagemolecular weight in the range of about 150 to about 1,000.
 7. Thecomposition according to claim 1, wherein the polymer for the fluid lossadditive is selected from the group consisting of: cellulose; guar;xanthan; starch; a monomer or monomers selected from the groupconsisting of acrylamido-methyl-propane sulfonate (AMPS),N-vinyl-N-methylaceamide, N-vinylformamide, N-vinylpyrrolidone,acrylonitrile, acrylamide, acrylomorpholine, vinyl alcohol, maleicanhydride, acrylic acid, methacrylic acid; derivatives of any of theforegoing; and any combination thereof.
 8. The composition according toclaim 1, wherein the polymer for the fluid loss additive has an averagemolecular weight in the range of about 50,000 to about 2,000,000.
 9. Thecomposition according to claim 1, wherein the fluid loss additive is ina concentration in the range of about 15% to about 80% by weight of thewell treatment composition.
 10. The composition according to claim 1,wherein the organophilic clay is selected from the group consisting oforganophilic bentonite, hectorite, attapulgite, sepiolite, and anycombination thereof.
 11. The composition according to claim 1, whereinthe suspending agent is in a concentration in the range of about 0.05%to about 5% by weight of the well treatment composition.
 12. Thecomposition according to claim 1, wherein the fluid loss additive is ina concentration in the range of about 0.05% to about 5% by weight of thecement.
 13. The composition according to claim 1, wherein the suspendingagent is in a concentration in the range of about 0.01% to about 2% byweight of the cement.
 14. A cement composition comprising: cement;water; and a well treatment composition, wherein the well treatmentcomposition comprises: (A) a water-soluble, organic liquid, wherein theorganic liquid: (i) comprises the continuous phase of the well treatmentcomposition; and (ii) comprises a polyglycol or a derivative ofpolyglycol; (B) a fluid loss additive, wherein the fluid loss additive:(i) is insoluble in the organic liquid; and (ii) comprises a highmolecular weight, water-swellable polymer; and (C) a suspending agent,wherein the suspending agent comprises an organophilic clay, wherein thewell treatment composition has an activity of at least 15%.
 15. Thecement composition according to claim 14, wherein the cement compositionhas a thickening time of at least 3 hours at a temperature of 125° F.(51° C.) and a pressure of 5,160 psi (36 megapascals).
 16. The cementcomposition according to claim 14, wherein the cement composition has asetting time of less than 48 hours at a temperature of 125° F. (51° C.).17. The cement composition according to claim 14, wherein the cementcomposition has a compressive strength of at least 500 psi (3.5 MPa)when tested at 24 hours, a temperature of 125° F. (51° C.), and apressure of 3,000 psi (21 MPa).
 18. The cement composition according toclaim 14, wherein the cement composition has an API fluid loss of lessthan 155 mL/30 min at a temperature of 125° F. (51° C.) and a pressuredifferential of 1,000 psi (7 MPa).
 19. The cement composition accordingto claim 14, wherein the fluid loss additive is in at least a sufficientconcentration such that the cement composition has an API fluid loss ofless than 155 mL/30 min at a temperature of 125° F. (51° C.) and apressure differential of 1,000 psi (7 megapascals).
 20. The cementcomposition according to claim 14, wherein the cement composition has adensity in the range of about 15 to about 20 ppg (about 1.8 to about 2.4kg/1).